Retrievable subsurface well bore apparatus



A. W. KAMMERER RETRIEVABLE SUBSURFACE WELL BORE APPARATUS March 3, 1964 4 Sheets-Sheet 1 Filed Sept. 21, 1959 FIIIIIII II II II II till 1 I I I I I v INVENTOR. W KAMMEEEE March 3, 1964 A. w. KAMMERER 3, I RETRIEVABLE SUBSURFACE WELL BORE APPARATUS Filed Sept. 21, 1959- 4 Sheets-Sheet 3 i .65 [100 I I 7 1' 95 T 3 $954 r 2 I10. 6. 5 f0 INVENTOR. flea/5e W KQMMEQEB March 3, 1964 Filed Sept. 21, 1959 A. w. KAMMERER 3,123,160 RETRIEVABLE SUBSURFACE WELL BORE APPARATUS 4 Sheets-Sheet 4 k-JO INVENTOR. flea/5e PK K IQMMEEEE United States Patent C) 3,123,16il RE'il tlEVABl-E SUEESURFA CE WELL 392E APlARATUS Archer W. l ammerer, 8% N. Raymond Ave, Fullerton, Cahh, assigner, by rnesne assignments, of thr e-lifths to said Archer W. Karnznerer, one-fifth to lean iii. Lampliere, and one-fifth to Archer W. Karnnserer, on, all of a u vr unerton, Gilli.

Filed Sept. 21, 195%, der. No. 841,379 (till, 175- 32) The present invention relates to subsurface well bore apparatus, including apparatus capable of being lowered through a string of pipe in the well bore, coupled thereto, and subsequently released therefrom for withdrawal through the pipe to the top of the well bore.

The usual manner of drilling well bores heretofore employed consisted in securing a bit to the lower end of the string of drill pipe and lowering such pipe in the hole to its bottom portion, the drill bit then being rotated to continue the formation of the well bore. As each bit becomes dull the drill pipe is removed from the well bore and another bit attached to it and the string of drill pipe relowered in the well bore. After the desired depth of the hole has been produced the drill pipe is removed and a string of casing, or the like, lowered in the hole, which may be cemented in place.

The necessity for frequent round trips to change drill bits is a time consuming and costly operation. Potential to the well bore is also present due to pressures and the like developed in the drilling mud, as a result of raising and lowering the string drill pipe. There is also the danger of being unable to lower the casing in the drilled hole to the required depth, or in damaging the well formation during lowering of t e casing.

Round trips are also necessary connection with the performance of other operations in the well bore, such as in drilling the hole to secure cores, or setting whipstoclrs for directional drilling or side tracking.

An object of the present invention is to provide an improved apparatus capable of being lowered through a string of pipe, which will form the casing for a well bore being produced, and of being readily coupled to the lower portion of the pipe, the apparatus being capable of performing an operation in the well bore below the pipe as a result of its being coupled to the latter, and of being released from the pipe and v ithdrawn therethrough to the top of the well bore.

Another object or" the invention is to provide directional ri .g apparatus capable of being lowered and removed through a string of pipe which will form the casing for the well bore, and of being readily cou led to the lower portion or" the pipe, ch can then be appropirately actuated to secure the required hole deviation and to drill the hole in the new dire on, the apparatus being releasable from the pipe and w drawn theretbrough to the top of the well bore. In a more limited sense, the apparatus is not only capable of producing the desired hole deviation, but of drilling the hole to the required diameter greater than the outside diameter of the string of pipe.

A further object of the invention is to provide coring apparatus capable of being lowered and removed through a string of pipe which will form the casing for the well bore, and of being coupled to tie pipe, which can then be rotated to produce the core while drilling the hole to the required diameter greater than the outside diameter of the pipe suing, the apparatus being releasable from the pipe and withdrawable therethrough to the top of the well bore.

An additional object of the invention is to provide apparatus for drilling a well bore that embodies a fluid turbine and drill bit combination capable of being lowered in and removed through a string of pipe which will form 3,lZ3,ld Patented Mar. 3, 1964 ice the casing for the Well bore, the apparatus being coupled to the lower portion of the pipe, to receive drilling fluid pumped down the pipe for the purpose or" rotating the turbine and the bit connected thereto, the apparatus also being adapted to be released from the pipe and withdrawn therethrough to the top of the well bore. The apparatus can produce a bore hole having a substantially greater diameter than the outside diameter of the string of pipe.

This invention possesses many other advantages, and has other objects which may be made more clearly apparent from a consideration of several forms in which it may be embodied. Such forms are shown in the drawings accompanying and forming part of the present specification. These forms will now be described in detail for the purpose of illustrating the general principles of the invention; but it is to be understood that such detailed description is not to be taken in a limiting sense, since the scope of the invention is best defined by the appended claims.

Referring to drawings:

FIGURE 1 is a side elevational view, partly in section, of a directional drilling apparatus disposed in a well bore;

Fit}. 2 is a side elevational View, partly in section, of another embodiment of the invention employed for producing and recovering a core from a well bore;

FIG. 3 is a longitudinal section through a portion of the apparatus for coupling or latching it to the lower end of a string of pipe disposed in the well bore, the coupling mechanism being in retracted position;

FIG. 4 is a View similar to FIG. 3, disclosing the coupling m chan sm in its expanded position and coupled to the string of pipe;

PEG. 5 is a longitudinal section through the upper portion of the apparatus disclosed in FIG. 4;

FIG. 6 is a crosssection taken along the line 6-6 on FIG. 3;

HG. 7 is a cross-section taken along the line 77 on FIG. 5;

FIG. 8 is a cross-section taken along the line 8-3 on FIG. 5;

P16. 9 is a side elevational view of the coupling portion of the apparatus;

FIG. 10 is a side elevational view, partly in section through another embodiment of the invention, that includes a fluid turbine for rotating a drill bit;

FIG. 11 is a longitudinal section, on an enlarged scale, through the latching portion of the apparatus disclosed in FIG. 10.

The apparatus disclosed in FIG. 1 is intended to produce a deviation from a well bore B previously drilled, and is capable of being lowered through a string of pipe A, such as well casing, which extends to the top of the well bore being drilled. The directional or hole deviation portion of the apparatus includes a whipstock 159 of any suitable type which is releasably secured to one or a plurality of drill pipe sections 151 in any suitable manner, as through use of a shear pin 152 attaching the upper portion of the whipstock to the drill pipe. The lower end of the drill pipe 151 has a suitable drill bit 153 attached thereto, which is adapted to be rotated in order to cause the hole to deviate by virtue of the engagement of the drill bit with the tapered face 154 of the whipstock.

The upper portion of the drill pipe 151 is suitably attached, as by means of its upper threaded pin 155, with the lower threaded box 15:? of an expandable coupling or latching and drilling apparatus C adapted to be coupled to the lower portion lb of the string of easing or pipe A. This coupling or drilling apparatus C, as well as the drill pipe 151, drill bit 153: and whipstock 15%, are adapted to be lowered through the string of casing disposed in the well bore and through a pilot hole D that may have been previously produced by a bit secured to the coupling and drilling mechanism. The coupling and drilling portion C of the apparatus will come to rest in the lower or shoe portion 10, of the casing, whereupon the entire casing A and apparatus C, 151, 153 can be lowered until the whipstock 15% engages the bottom of the pilot hole D, the casing A being properly oriented so as to appropriately orient the whipstock and insure that the drill bit 153 will produce the hole deviation in the proper direction.

The coupling and drilling mechanism is disclosed most clearly in FIGS. 3 to 9, inclusive. As specifically shown, it includes an elongate body 12 having a lower threaded box 156 to which the upper pin end 155 of the drill pipe is secured. Above its threaded box, the body 12 of the coupling device has a transverse slot area 16 in which a plurality, such as a pair, of coupling or latching members 17 are mounted. These coupling or latching members may also include cutters 11 for enlarging the diameter of the well bore B to a size substantially greater than the outside diameter of the string of pipe A. The coupling or cutter supporting members 17 are disposed in the elongate body slot 16, being pivoted on hinge pins 18 extending across the slot and suitably secured to the body 12. Each cutter supporting member 17 carries a cutter member 11, such as a conical tooth cutter, which, when expanded outwardly in the manner described hereinbelow, will be coupled to the shoe it) of the pipe A, and can also function to drill the hole B to the diameter substantially greater than the outside diameter of the string of well casing A and enlarge the diameter of the pilot hole D previously drilled, as by a pilot drill bit.

The coupling members 17 and cutters ll normally occupy an inward position, such as disclosed in FIG. 3, in which they are retracted substantially fully within the confines of the body 12 of the tool. They are expanded outwardly of the body to be coupled to the casing A as a result of downward movement of a mandrel device 19 within the body 12. As shown, the mandrel device includes an upper piston portion 29 slidable within a cylinder 21 in the body, leakage of fluid between the piston and cylinder being prevented by a suitable seal device 22, such as a rubber or rubber-like O ring, in an internal groove 23 in the body slidably and sealingly engaging the periphery of the piston.

Secured to the piston 26 and depending therefrom is a tubular member portion 24 of the mandrel, a lower part of which is slidable through a guide 25 extending across the body slot 16 and attached to the body 12. The upper portion of the tubular member 24 is piloted within the piston Zil, its upper end engaging a downwardly facing piston shoulder 27. Downward movement of the tubular member 24 with respect to the piston 2% is prevented by a row of balls 28 which engage a downwardly facing raceway 29 on the tubular member and which are received within an internal raceway 39 in the piston. The balls 28 are insertable through a radical hole 31 in the piston which may be closed by threading a suitable plug 32 in such hole, as disclosed in FIGS. 3 and 4. Leakage of fluid between the piston and tubular member is prevented by a side seal ring 33.

When the piston 24B and tubular member 24 move downwardly, an expander 34 mounted on and fixed to the tubular member 2 engages downward and inwardly tapering expander surfaces 35 on the cutter supporting members or coupling members 17, to pivot the latter and the cutters 11 about the axes of the hinge pins 13 and shift the cutters 11 outwardly. When the cutters have been shifted outwardly to their maximum extent, holding surfaces 36 on the expander 34 will be disposed behind companion holding surfaces 37 on the supporting members below their respective expander surfaces 35, preventing inadvertent retraction of the cutter supporting members or latches l7 and cutters 11 from their expanded position. The piston and tubular member portion 2a, 241 of the mandrel are shif a e own y to the maximum extent determined by engagement of the lower end of the expander 3 with the guide 25 at which time the lower end of the tubular member is piloted within a body passage 25a below the slot 16.

As specifically illustrated in the drawings, the mandrel 1% is normally urged in an upward direction and held in such position, in which the expander 34 is disposed above the expander surfaces 35 on the coupling or cutter supporting members 17', by a helical compression spring 38 disposed in the cylinder 21 below the piston 2% the upper end of the sprin' engaging the lower end of the piston and the lower end engaging a lower spring seat 3? formed in the body 12 of the coupling mechanism C.

The mandrel member 19 is shiftable downwardly to expand the coupling members 17 and cutters 11 in response to fluid pressure developed in the body 12 of the tool above the piston 29, which is obtained by pumping drilling mud, or similar fluid, down through the casing string A. Such fluid will flow through the upper end of the body 12 and then through inlet ports 4% in the mandrel 19 above its piston portion 24 into a central passage 41 extending through the tubular member 24. Such fluid under pressure flows through a nozzle 42 in the tubular member and discharges into the body passage 25a. Because of the throttling action provided by the inlet ports 46, or by the nozzle 42, a back pressure is built up in the body 12 above the piston 29 which will urge the latter downwardly against the force of the spring 38 and urge the mandrel 1% and its tubular member 24 downwardly to etfect outward expansion of the cutter supporting or coupling members 17 and the cutters 11 carried thereby.

Once the coupling members 17 and the cutters 11 have been expanded outwardly they are releasably locked in such outwardly expanded position. To accomplish this purpose a carrier member 43 forms an upper extension of the mandrel 19. The lower end 44 of this carrier member is piloted into the upper head portion 45 of the mandrel, being suitably secured thereto as through use of welding material 46. This carrier extends upwardly through a spider or latch sleeve 47 mounted in the upper end of the body 12, having inwardly directed ribs 43 circumferentially spaced from one another and which are engageable with the periphery of the carrier. The latch sleeve 47 is held within the body by a split snap retainer ring 49 overlying the upper end of the sleeve and disposed within an internal groove 50 in the body, downward movement of the latch sleeve 47 in the body being prevented by engagement of a sleeve flange 51 with an upwardly directed body shoulder 52.

The carrier member 43 has an elongate slot 53 (FIG. 5) extending therethrough receiving a latch member 54 pivotally mounted on the hinge pin 55 extending across the carrier slot and suitably secured thereto, as by welding. The latch 54 also extends within a slot 56 in a retrieving plunger 57 movable longitudinally in a bore 58 in the latch carrier 43, downward movement of the plunger within the carrier being limited by engagement of a plunger flange 59 with the upper end of the carrier. The latch 54 is swingable outwardly of the carrier 43 under the influence of a helical compression spring 6t one end of which engages the inner wall of the carrier 43 and the other end of which engages an upwardly extending lug or spring seat 61 on the latch to force a latch finger 62 outwardly of the carrier slot and under one hi the ribs 48 of the spider 47. The carrier slot 53 and the latch 54 disposed therein are aligned with one of the ribs 48 by attaching screws 63 to the carrier 43 on the opposite sides of another rib 48, thereby maintaining the orientation of the latch 54 relative to a spider rib.

Initially, the mandrel l9 and carrier 43 attached thereto are disposed in an upward position within the body 12 of the coupling or drilling device (FIG. 3). At this time, the latch finger 62 is disposed inwardly of the carrier 43 and engages the inner surface of one of the spider ribs 48. However, when the mandrel 1 is moved downwardly by the pressure of the fluid pum ed down the casing string A, the carrier 43 and latch 54 move downwardly with it until the latch finger is disposed below the rib :3, the spring 69 then swinging the latch 54- outwardly until its finger 62 is under the rib (FIG. 5). The return or retracting spring 38 engaging the underside of the mandrel piston 21 is then incapable of elevating the mandrel 19 within the body 12 of the drill bit and coupling device C.

When the latch 54 is in its latching position, such as shown in FIG. 5, the hinge pin 55 in the latch is relieved of the latching force. The hole 65 in the latch is made elongate, permitting a slight longitudinal shifting of the latch 54 within the carrier slot 53 and across the pin. Thus, when the upper end of the latch finger 62 engages the lower end of the rib 48, the lower end 65 of the latch will engage the lover side 67 of the carrier defining the carrier slot 53. It is evident from FIG. 5 that the hinge pin 55 is relieved of the thrust transmitted through the latch 54 between the carrier 43 and the spider 47.

The latch 54 is released whenever the coupling or supporting members 17 and cutters 11 are to be retracted, by moving the retracting plunger 57 upwardly. This plunger has a retrieving pin 68 secured thereto which is slidable in diametrically opposed longitudinal slots ea in the carrier and which pass through an opening it? in the latch. Initially, the retracting pin 63 is in the lower position within the carrier slot 69 and the latch opening 7%. When in this position, the latch 62 is free to swing outwardly under the influence of its spring tl, upon lowering of the mandrel 19 within the body 12. At this time, it is to be noted that the left side 71 of the latch opening 79, as seen in 5, is inclined in an upward and out ward direction. Accordingly, when the retracting plunger 57 is elevated within the carrier 43, the retracting pin 68 engages the inclined side 71 of the latch 54 and swings it inwardly against the force of its spring b3, and completely within the confines of the carrier 4-3, thereby releasing the latch finger 62 from the spider rib 48 and allowing the entire mandrel 1% to move upwardly within the body 12 of the tool.

In the event that the retracting spring 38 is used, it may exert suflicient force to elevate the mandrel 19 within the body 12, thereby allowing the coupling members 17 and cutters 11 to return to their retracted position. However, if the retracting spring 33 is not used, then the elevation of the retracting plunger 57, to release the latch 54, will bring its pin 63 in contact with the carrier 43 at the upper end of the longitudinal slots 69, whereupon the upward force on the retracting plunger 57 will be transmitted through the retracting pin 68 to the carrier 43, which is actually a part of the mandrel 19, the mandrel then being forcibly moved upwardly within the body 12 of the tool. If the elevation of the expander 34 above the expander surfaces 35 on the coupling or cutter supporting members 17 does not result in the latter and cutters 11 moving inwardly under the force of gravity to their retracted position within the body 12, the upward movement of the mandrel will cause a retracting flange or shoulder 75 on the mandrel to engage the upper, inner arms 76 on the coupling or cutter supporting members 17, and shift such arms upwardly, pivoting the portion of the coupling or cutter supporting members 17 below the hinge pins 13, and the cutters 11 themselves, inwardly back within the confines of the body slot 16.

The coupling and drilling apparatus C, and the apparatus depending therefrom, are adatped to move downwardly through the entire string of casing A to the shoe portion of the latter with the drill pipe 151, lower drill bit 153 and whipstock 152 extending below such shoe portion. The apparatus can move downwardly to the extent limited by engagement of a stop ring or thrust collar 77 on the upper portion of the body 12 with a stop shoulder '78 provided in the casing shoe. When the stop ring 77 engages the casing shoulder 78, the drill pipe 151, drill bit 153 and whipstock 150 are all disposed substantially below the lower end of the casing shoe 14 whereas the lower portion 17a of each coupling or cutter supporting member 17 is disposed within a slotted coupling portion 79 at the lower end of the shoe, each cutter 11 being located below the lower end 80 of the shoe.

The cutter supporting members or coupling members 17 are expandable outwardly, to be shifted within slots 31 of the lower portion of the shoe. Each slot is sufficiently wide to accommodate a coupling or cutter supporting member 17, and each slot has a driving face 82 adapted to engage the side of a coupling member for the purpose of rotating the latter or to prevent relative rotation between the latter and the casing A. The upper end 83 of each slot is defined by a thrust shoulder or surface on the shoe adapted to engage a companion shoulder or step 8-4 on the member 17.

The coupling or cutter supporting members 17 are shiftable outwardly of the body of the tool to the extent limited by engagement of an exterior surface 85 on each coupling or supporting member, above its stop shoulder 34, with the inner surface 36 of the casing shoe. Thus, the inner surface 85 of the casing shoe limits the extent of outward expansion of each coupling or cutter supporting member 17, whereas the holding surfaces Ed on the expander 34 coact with the companion holding surfaces 37 on the members 17 to prevent inward movement of the latter.

The driving face 32 on the shoe, which will engage a companion face on the coupling or cutter supporting member 17, is preferably flat so that a substantial surface engagement is had between the driving face and the side face of the coupling or cutter supporting member. The opposed side of each slot 31 is curved, the curve runing from the inner surface of the casing shoe 10, and then toward its outer surface in a direction toward the driving face 82 of the slot, such as shown most clearly in FIG. 6. The curved guide surface 83 will be engaged by the outer suriace 1% or corner 9% of a coupling or cutter supporting member 17 when it is being expanded outwardly by the mandrel 19 shifting downwardly within the body 12. In the event that the cutter supporting members or coupling members 17 are not aligned with a pair of diametrically opposed slots 81, the outer force will cause the coupling members 17 to slide along the curved guide surfaces 88 and shift them to their outward position until they move fully within the slots 81. Such arcuate shiiting of the cutter supporting members 17 is accompanied by arcuate shifting of the body ll? of the tool. T o facilitate such arcuate shifting, a reliable type of bearing connection is provided between the stop ring or thrust collar 77 and the body of the tool. As shown, a set of balls 91 is mounted in an external raceway M: in the upper portion of the body 12 and these balls engage a companion upwardly facing raceway 93 on the thrust ring 77. The balls 91 can be inserted between the raceways through a radial hole 9 in the body 12 of the tool which is then closed by a suitable plug 95.

in the event that the coupling or cutter supporting members 17 and cutters 11 are being expanded outwardly and the members 17 are disaligned with the slots 81 they might engage the curve corner 98 between the driving face 32 and one slot and the curve guide surface 88 of an adjoining slot. Because of the curved exterior 1125 of each coupling or cutter supporting member 17, if it does not slide in a clockwise direction, as seen in FIG. 6, along the curved guide surface 38, it will slide along the corner 93 in a counterclockwise direction into alignment with one of the slots 81, whereupon the cutter supporting or coupling member 17 is expandable fully outwardly to bring its stop surface 85 into engagement with the internal surface 86 of the shoe 1%, and with its shoulder 84 under and adjacent to the downwardly directed thrust surface or shoulder 33 on the shoe. When the coupling members 17 and cutters 11 are locked in their expanded position by the latch 54, the supporting members 17 and cutters cannot move upwardly of the shoe 1t which is also true of the body 12 of the tool, while the body of the tool itself cannot move downwardly of the shoe 19 by virtue of the engagement of the thrust collar 77 with the stop shoulder 7 S on the body.

' A bit, such as the lower drill bit or pilot bit 153, will have previously drilled the pilot hole D, which may have been previously accomplished in the absence of the whipstock 159 attached to the drill pipe 151. This pilot hole D is slightly less in diameter than the minimum diameter through the casing shoe 11). The expansible cutters 11 when expanded outwardly will form and operate upon a transverse shoulder E in the formation that extends from the wall of the pilot hole D to the desired enlarged diameter of the well bore B, which is substantially greater than the outside diameter of the casing string A. Drilling mud can now be pumped down through the casing string, and is prevented from passing around the exterior of the body 12 because of the provision of suitable side seal rings 98a, such as rubber rings, disposed in peripheral grooves 99 in the body and sealingly engaging the inner surface 8:; of the casing shoe below its stop shoulder 73. The fluid will then flow through the passages 1 between the spider ribs 48 and the carrier 43, passing into the body 12 and downwardly around the carrier, continuing on through the inlet ports .1) and through the tubular member passage 41 and through the nozzle 4-2. The extension of the tubular member fits within the body passage 25a when the cutters 11 are in their expanded position, such as disclosed in FIG. 4, the fluid discharging into such body passage and then into the drill pipe 151 connected to the body. The circulating fluid will flow downwardly through the drill pipe and will discharge through the usual nozzles (not shown) in the drill bit 153. Such fluid will remove whatever cuttings have been formed by the drill bit and carry them upwardly around the exterior of the drill pipe 151 and also around the expandable cutters 11, cleaning the latter of their cuttings and the cuttings on the formation shoulder E, flushing all of the cuttings upwardly around the exterior of shoe 1% and the casing A back to the top of the hole.

In the use of the apparatus, the coupling members 17 and the cutters 1-1 are initially in their retracted position disclosed in FIG. 3, the drill pipe 151 being threadedly attached to the lower end of the body 12 and also releasably secured to the whipstock 15%, as by means of the shear pin 152, the drill bit 153 being disposed at the upper portion of the whipstock. At this time, the latch 54 is also in its retracted position in engagement with the inner surface of a rib 48 with which it is oriented. The entire apparatus is dropped into the string of pipe or casing A, and will gravitate or can be pumped through the drilling mud therewithin until the thrust ring '77 engages the stop shoulder 73. At this time the drill pipe 151 will extend into the pilot hole D, which is also true of the whipstock 156'. Fluid can now be pumped down through the string of casing A, passing into the body 12 of the tool and exerting a pressure on the piston portion 26 to shift it downwardly and cause the mandrel expander 34 to engage the expander surfaces 35 of the coupling or cutter supporting members 17 to expand the latter and the cutters 11 outwardly. The coupling members 17 will shift outwardly, and if disaligned with a pair of opposed shoe slots 81 they will engage either the curved guide surfaces 88 or the corners 98 of the shoe, to be shifted into alignment with the opposed slots 81, whereupon they will move outwardly within the slots to the extent determined by engagement of the upper exterior surfaces 85 of the members 17 with the inner surface 86 of the shoe 1%, at which time the thrust shoulders 84 on the coupling or supporting members are disposed under and closely adjacent to, if not against, the thrust shoulders 33 on the shoe. The expander 34 will also have moved downwardly to its maximum extent, in which its holding surfaces 36 are disposed behind the companion surfaces 37 on the inner portions of the coupling members 17. When this occurs the latch 54 will have been shifted outwardly by the spring 6%? to dispose its finger 62 under a spider rib 48,-

The entire casing string A can then be lowered, the

casing string having been properly oriented to insure that the inclined face 154 of the whipstock is located in the proper direction. The casing string is then lowered until the whipstock 15d engages the bottom of the hole D, the downward force being transmitted from the casing shoe 19 and through the coupling members 17 to the hinge pins 13, and from the latter through the body 12 of the apparatus, the drill pipe 15-1 and the shear pin 152 to the whipstock. When sufficient downweight is imposed, the shear pin 152 will be disrupted, whereupon the drill bit 153 slides along the inclined face 154 and against the opposed side wall portion of the pilot hole D. The casing string A is then rotated at the proper speed and the desired drilling weight imposed thereon. The rotary effort or torque is transmitted through the coupling members 17 to the body 12 of the tool, and through the drill pipe 151 to the bit 1:33. The drilling bit 153 will be deflected from the axis of the hole'in which the whipstock is lowered, and it will produce a hole D1 deviated from such axis, as the apparatus is rotated and the appropriate drilling weight applied to the bit. During the drilling action of the bit 153, drilling mud is pumped down through the casing string A, this drilling mud passing through the mandrel 19 into the drill pipe 151 and from the nozzles (not shown) of the drill bit to carry the cuttings upwardly around the drill pipe to the top of the hole.

During the production of the deviated or directional hole D1 the expanded cutters 11 may engage the transverse shoulder E. When this occurs, they will enlarge the previously drilled well bore D to a diameter greater than the outside diameter of the casing string A. The cuttings produced by such cutters 11 will be flushed from the cutting region by thedrilling mud that has passed out of the drill bit 153, and which is flowing upwardly around the drill pipe .151. The cuttings are flushed by such drilling mud upwardly around the casing A to the top of the hole B. I

The apparatus, with the exception of the whipstock 15d, can be withdrawn from the well bore whenever desired without removing the casing string A from the hole. Such action can occur by lowering a suitable overshot (not shown) on a sand line (not shown) through the casing string A, the overshot coupling itself to the head 11% of the retrieving plunger 57, which can then be pulled upwardly. Such upward pulling will cause the retrieving in 68 to release the latch 54 from the spider rib 48, after which the mandrel 19 will shift upwardly within the body 12 to elevate the expander 34 above the expander surfaces 35 and the coupling cutter supporting members 17. These members 17 will now shift inwardly. If need be, to insure such inward shifting the casing string A may be elevated a slight distance to remove the expanded cutters 11 from contact with the transverse formation shoulder E. Upward movement of the sand line will now result in upward movement of the entire apparatus, in cluding the drill pipe 151 and the drill bit 153, through the casing A to the top of the hole.

Another pilot bit 153, or the like, can be attached to the drill pipe in place of the worn pilot bit and the entire apparatus again relowered through the casing string until the thrust string '77 engages the casing shoulder '78. The drilling fluid is again circulated down through the string of casing to shift the mandrel 19 downwardly to again expand the coupling members '17 and the cutters 11 outwardly, until the coupling members are securely locked to and within the casing shoe it in the manner disclosed in FIG. 4, the latch 54 preventing inadvertent upward amazes movement of the mandrel 19 within the body 12. of the tool, the bit 153 will slide along the whipstock 15d and into the hole D1, whereupon drilling can continue.

By the expedient of coupling and releasing the apparatus C from the well casing A, the deviated pilot hole D1 can be drilled to the desired extent, without the necesity for removing the casing string A from the well bore.

After the pilot hole has been drilled to the desired depth, the apparatus need merely be removed through the casing string to the top of the hole, without removing the casing string, which can be employed for subsequent drillin or other operations in the well bore.

In the embodiment of the invention disclosed in FIG. 2, the drill pipe, pilot bit and whipstock have been repl ced by a coring apparatus 2%, since it is desired to secure core samples from the formation being drilled. The coupling portion C of the apparatus may be the same as disclosed in FIGS. 3 to 9, inclusive. The core bit 2%, which is disclosed only diagrammatically in FIG. 2, and which may be of any suitable type, has its upper threaded pin 2 31 tnreadedly attached to the lower threaded box 156 of the body 12 of the tool C. The outside diameter of the coring apparatus 2% is slightly less than the minimum diameter through the casing string A, so that it does not interfere with downward movement of the apparatus through the casing, as well as its upward retrieval therethrough. The core bit may have the usual drilling head 2492 at its lower end which will drill, a pilot hole in the formation having a diameter but slightly less than the inside diameter of the string of pipe or casing A. This core head will also produce a core 2%?) by only operating upon the outer annular margin of the bottom of the hole D that will move relatively upwardly in the corin apparatus, in a known manner, during rotation of the coring apparatus.

The apparatus is lowered or pumped down through the casing string A with the latching members 17 and cutters 11 in their retracted position, such as disclosed in FIG. 3. When the lower end of the casing string is reached, the thrust ring 77 will have engaged the casing shoulder 78, the coring appmatus Zilll then being disposed substantially below the lower shoe 1d of the casing, with the expandable cutters 11 also disposed below the lower end of the casing shoe. The drilling fluid is circulated down through the string of casing A to smft the mandrel downwardly, expanding the coupling members 17 and the cutters ll outwardly until the coupling members move within the shoe slot 81 and are securely locked within the casing shoe it), in the manner described above. The entire casing string A is then rotated, the turning effort being transmitted through the shoe it? and the coupling memers l? to the body 12 of the apparatus, which then effects rotation of the coring apparatus attached thereto. The downward drilling weight is imposed on the coring apparatus 2% throu h the steps or shoulders $4 of the coupling members 17, this weight being transmitted through the hinge pins 13 to the body 12 of the tool and to the coring apparatus itself The casing string A and the apparatus coupled to it are rotated at the proper speed, with the appropriate drilling weight applied thereto, and with drilling mud pumped down through the casing A, which will pass through the core bit Ztlll for discharge from its lower end outwardly of the core 233 being produced, the cuttings being removed by the drilling mud and passing upwardly around the core bit, the drilling mud also collecting the cuttings produced by the expanded cutters 11, which are engaging the transverse formation shoulder E, and conveying all of the cuttings upwardly around the casing A to the top oi the hole The core bit 2% produces the pilot hole D, whereas the expanded cutters l1 enlarge the size of such hole to a diameter that is substantially greater than the outside diameter of the casing string A.

After the required length or" core 293 has been produced, the entire apparatus C, 2% is released from the casing A and withdrawn upwardly therethrough to a top or" the hole, in the same manner described in connection with the other form of the invention. The core 293 is removed from the apparatus Elli? at the top of the hole, whereupon the apparatus may again be lowered or pumped down through the casing string A, coupled in place, and the coring operation continued.

t is apparent that with the apparatus disclosed in FIG. 2, cores can be secured and recovered without the necessity for removing the casing string A from the well bore. in addition to the cores being produced, the hole B can be drilled to the required outside diameter by the expanded cutters 11. Thus, the members 17 not only function to couple the coring apparatus Zilil to the casing A, but also to rotate the expanded cutters 11 around the formation shoulder E, while suitable drilling weight is being applied thereto to enlarge the well bore to the required diameter.

the form of invention disclosed in FIGS. 19 and 11, the releasable coupling portion C of the apparatus is designed to secure an axial llow turbine 3% and drill bit 3% combination to the string of pipe or casing A, in order that the turbine can be utilized to rotate the drill bit and produce the well bore B to the desired diameter. The apparatus disclosed can be lowered through the string 01"- pipe and coupled to its lower portion. It can be uncoupled or released from the pipe and then withdrawn completely tlu ough its interior to the top of the well bore.

The releasable and retractable coupling portion C or" the apparatus is essentially the same as disclosed in connection with the other forms of the invention heretofore described, except that the expandable cutters 11 are not mounted on the coupling or latch members 17, inasmuch as in the form of invention disclosed, the expansible drill bit Si l, secured to the lower portion of the fluid turbine will drill the hole B to the required diameter substantially greater than the outside diameter or the casing string A. However, the coupling members 17 are expanded outwardly in response to downward movement of the mandrel 19 within the body 12 of the tool, as in the other form of the invention, to enter the slots 31 of the casing shoe l6 and become rotatationally coupled to the casing A. Moreover, downward drilling weight is also transmitted from the casing A through the coupling members 7 to the body 12 of the tool, and then to the ap paratus Sill depending therefrom.

The axial fiow fluid turbine 39% can be of a known type, and includes an outer stator 3%.; that may have an upper threaded pin 3 33 for threadedly attaching it to the lower box 355 of the body 12 of the coupling portion C of the tool. A rotor 394 is rotatably mounted in the stator and may have a threaded box 335 in its lower portion to which is threadedly attached the upper pin end 3% of the rotary drill bit Sill, that may have a lower pilot portion 3&7 and expandable cutters 368 that may be retracted Within the confines oi the body 3 59 of the lower bit when the latter is being moved through the casing string A. The pilot bit 3tl7 has a diameter slightly less than the m nimum diameter through the casing string A, which is also true of the efiective diameter of the expansible portions of the bit Sill when its cutters 308 are in their retracted position. Such cutters are expandable outwardly to an extent to drill the required diameter of the well bore B, which will 'be substantially greater than the outside diameter of the casing strin The expansible drill bit 3&1 may be of any suitable type, such as the bit disclosed in United States Patent No. 2,863,641, to which attention is invited. Not only can the expandable cutters of this bit be placed in retracted position in moving the apparatus through the string of pipe or casing A, but the stator 3%2 itself has a maximum outside diameter that is slightly less than the minimum diameter of the casing string, such that the entire apparatus can be lowered in the casing string A, as well as removed therethrough to the top of the hole.

Initially, the lower bit 34H has its cutters 3% in their retracted position. It is secured to the lower end of the turbine rotor 3M and the upper end 3% of the turbine stator 302 is secured to the body 12. of the coupling portion C of the apparatus, the coupling members 17 of which are then in their retracted position. The entire apparatus is lowered or pumped down the casing string A until the thrust ring 77 engages the stop shoulder 7 3. At this time the coupling members 17 will be disposed in the region of the casing slots 81, with the turbine 3% and the expans-ible drill bit 3% extending below the lower end of the casing shoe 10. The drilling fluid is now pumped down through the casing A, and such fluid will pass into the coupling portion C of the tool to act on its piston and shift the mandrel l9 downwardly within the body 12. Such down- Ward shifting will expand the coupling members 17 outwardly until they are disposed fully within the shoe slots 81, thereby eflectively coupling the apparatus C to the casing A, the upper latch 54 then being urged outwardly and under the spider rib 48 to prevent return movement of the mandrel 19 within the body 12, which might release the coupling members 17 from the casing shoe The return spring 38 may or may not be used, which has the purpose of urging the mandrel l9 upwardly within the body 12 of the tool.

The drilling fluid pumped down the casing A will flow through the mandrel 19 and into the lower portion 25a of the body 12 below the body slot 36. Such fluid under pressure will then flow into the turbine and will turn the rotor 3 .24 of the latter, this rotary motion being transferred to the lower expandable bit Frill. The expandable bit disclosed in the above-identified patent is of the hydraulic type, in which the fluid under pressure flowing through it will also cause the cutters 3% to be urged laterally outwardly. It is unnecessary to rotate the casing A in performing the drilling operation, since the rotary eflort or torque is being supplied by the axial flow hydraulic turbine 30!). The appropriate drilling weight is imparted to the casing string A and through the coupling members 17 to the body 12 of the tool, such drilling weight also being imparted through the hydraulic turbine 3th) to the expansible drill bit 391 and on to the formation shoulder E that the eXpansib-le cutters 3% of the latter produce, as well as on to the pilot bit 397 which forms the pilot hole D in advance of the expanded cutters 398. The turbine 3% rotates the entire bit 3%, the fluid flowing outwardly through the expansible portion of the tool 361, or the pilot bit 367, or both, to remove the cuttings from the drilling region and carry them upwardly around the lower bit Sill, the hydraulic turbine 343i) and around the string of casing A to the top of the hole.

In the event that the bit cutters 3 38, 397 become dull, the pumping action may cease and a suitable overshot (not shown) lowered on a sand line or other wire line (not shown), the overshot becoming coupled to the upper head 11% of the plunger 57, in order to release the latch 54 and elevate the mandrel 19 within the body 12 of the tool, thereby allowing the coupling members 17 to retract from the casing A and uncouple the latter from the casing shoe The wire line is now elevated to withdraw the coupling mechanism C, the turbine 3G0 and the expandable tool 301 upwardly through the casing A to the top of the hole, the expandable cutters 368 of the tool shifting to their retracted position, as described in the above-identifled Patent 2,863,641.

Another tool 301 may now be attached to the lower end of the turbine 369, or the worn cutters 367, 398 replaced with sharp cutters, and the apparatus again lowered in the well casing until the thrust ring 77 engages the stop shoulder 78. The pumping of drilling mud, or other fluid, down through the casing string A will again eflect a i e-expansion of the coupling members 17 into the shoe slots 81, as well as a rotation of the turbine 3%, and expansion of the cutters 368 of the lower bit Sill outwardly, whereupon appropriate drilling weight-can be applied to i2 the cutters 3%7, 303 to continue the drilling of the well bore.

The foregoing cycle of operation can be repeated as often as necessary to drill the hole B to the required depth. Of course, as drilling proceeds, additional sections of casing A are added at the top of the hole. After the drilling operation has been completed, the coupling apparatus C, with the turbine 30 3" and drill bit 361 attached thereto, are removed through the casing A to the top of the hole. The casing A may, if desired, be cemented in place.

It is evident that the entire hole B can be drilled without removing the casing, there-by saving substantially in round trips.

Aldrough the hole can be drilled without turning the casing A, since the turning efiort is supplied by the hydraulic turbine 3%, to insure against sticking of the casing in the well bore, it may be turned slowly during the drilling operation.

The inventor claims: 7

l. In combination: a string of pipe adapted to be lowered within a well bore; a coupling device movable longitudinally through said pipe and including an initially retracted coupling member; a well tool secured to said coupling device and depending therefrom and movable longitudinally through said pipe; said pipe having stop means therein at its lower portion; said coupling device having stop means above said coupling member engageable with said other stop means to locate said well tool substantially below the lower end of said pipe and to prevent further downward movement or said coupling member relative to said pipe; fluid actuated means including a tubular mandrel engageable with said coupling member for expanding said coupling member outwardly into coupling engagement with said pipe after engagement of said stop means with each other; said fluid actuated means being responsive to the pressure of the fluid in said pipe to expand said coupling member; said tubular mandrel communicating with said well tool and with the pipe above said mandrel to conduct fluid from said pipe through said mandrel to the interior of said well tool; seal means between said coupling device and pipe preventing fluid flow therebetween when said stop means are engaged with each other to cause all of the fluid pumped down the pipe to flow through the tubular mandrel into said well tool; means for transmitting downwardly directed thrust from said pipe to said coupling device and to said tool; and means for retracting said coupling member from coupling engagement with said pipe to enable said coupling device and tool to be withdrawn through said pipe to the top of the well bore.

2. In combination: a string of pipe adapted to be lowered within a well bore; a coupling device movable longitudinally through said pipe and including an initially retracted coupling member; an apparatus including a drill bit secured to said coupling device and depending therefrom and movable through said pipe; a whipstock releasably attached to said apparatus and movable through said pipe; said pipe having stop means therein at its lower portion; said coupling device having stop means above said coupling member engageable with said other stop means to locate said drill bit and whipstock substantially below the lower end of said pipe and to prevent further downward movement of said coupling member relative to said pipe; fluid actuated means including a tubular mandrel engageable with said coupling member for expanding said coupling member outwardly into coupling engagement with said pipe after engagement of said stop means with each other; said fluid actuated means being responsive to the pressure of the fluid in said pipe to expand said coupling member; said tubular mandrel communicating with said apparatus and with the pipe above said mandrel to conduct fluid from said pipe through said mandrel to the interior of said apparatus and its drill bit; seal means between said coupling device and pipe preventing fluid flow therebetween when said stop means are engaged with each other to cause all of tie fluid pumped down the pipe to flow through the tubular mandrel into said apparatus; means for transmitting dowi warly directed thrust from said pipe to said coupling device and to said drill bit and wlnpstock; and s for retracting said coupling member from coupling engagement with said pipe to enable said coupling device drill bit to be withdrawn through said pipe to the top of the well bore.

3. In combination: a strin: of pipe adapted to be lowered within a well b re; a coupling device movable longitudinally through said pipe and including an initially retracted coupling member; a core bit apparatus secured to said couplin device and depending therefrom and movable longitudinally through said pipe; said pipe having stop means therein at its lower portion; said coupling device having stop means above said coupling member engageable with said other st' p means to locate said core bit apparatus substantially below the lower end of said pi e and to prevent further downward movement of said co.pling mem-er relative to said pipe; fluid actuated means including a tubular mandrel engageable with said coupling member for expanding said coupling member outwardly into coupling enga ement with pipe after engagement of said stop means with each other; said fluid actuated means being responsive to the pressure of the fluid in said pipe to expand said coupling member; said tubular mandrel communicating with said core bit apparatus and with the pipe above said mandre to conduct fluid from said pipe through said mandrel to the interior of said core bit apparatus; seal means between said coupling device and pipe preventing fluid ilow therebetween when said stop means are engaged with each other to cause all of the fluid pumped down the pipe to flow through the tubular mandrel into said core bit apparatus; means for transmitting downwardly directed thrust from said pipe to sai coupling device and to sai core bit apparatus; and means for retracting said coupling me nber from coupling engagement with said pipe to enable said coupling device and core bit apparatus to be withdrawn through said pipe to the top of the well bore.

4. in combination: a string of pipe adapted to be lowered within a well bore; a coupling device movable longitudinally through said pipe and including an initially retracted coupling member; a fluid turbine secured to said coupling device depending therefrom and movable longitudinally through said pipe; a drill bit secured to said turbine; said p' e having stop means therein at its lower portion; said coupling device having stop means above said coupling member engageable with said other stop means to locate said fluid turbine and drill bit substantially below the lower end of said pipe and to prevent further downward movement of said coupling member relative to said pipe; fluid actuated means including a tub 2r mandrel engageable with said coupling member for expanding said coupling member outwardly into coupling engagement with said pipe after engagement of said stop means with each other; said fiuid actuated means beiri responsive to the pressure of the fluid in said pipe to expand said coupling member; said tubular mandrel communicating with said fluid turbine and with the pipe above said mandrel to conduct fluid from said pipe through said mandrel to the interior of said fluid turbine to rotate the same and the drill bit secured thereto; seal means between said coupling device and pipe preventing fluid flow therebetween when said stop means are engaged with each other to cause all of the fluid pumped down the pipe to flow through the tubular mandrel into said fluid turbine; means for transmitting downwardly di rected thrust from said e to said coupling device and to said turbine and drill bit; and means for retracting said coupling member from coupling engagement with said pipe to enable said coupling device and said turbine and drill bit to be withdrawn through said pipe to the top of the well bore.

5. In combination: a string of pipe adapted to be lowered within a well bore; a coupling device movable longitudinally through said pipe and including an initially retracted coupling member; drill pipe secured to said coupling device and depending therefrom; a drill bit secured to said drill pipe; a whipstock rel asably attached to said drill pipe and movable through said string of pipe; said string of pipe having stop means therein in its lower portion; said couplin device having stop means above said couplin member engageable with said stop means to locate said drill "ipe, whipstock and drill bit substantially below the lower end or" said strin of pipe and to prevent urther downward movement of said coupling member relative to said pipe; fluid actuated means including a tubular mandrel engageable with said coupling member for expanding said coupling member outwardly into coupling engagement with said string of pipe after engagemerit of said stop means with each other; said fluid actuated means being responsive to the pressure or" the fluid in said pipe to expand said coupling member; said tubular mandrel communicating with said drill pipe and with the string of p-e above said mandrel to conduct from said string of pipe through said mandrel to the interior or" said drill pipe and to said drill bit; seal means between said coupling device and pipe preventing fluid flow therebetween when said stop means are engaged with each other to cause all of the fluid pumped down the pipe to flow through the tubular mandrel into said drill pipe; means for transmitting downwardly directed thrust from said string of pipe to said coupling device and to said drill pipe, drill bit and whipstock; and means for retracti' said coupling member from coupling e engagement with said string of pipe to enable said cou-; plin device, drill pipe and drill bit to be withdrawn through said string or" pipe to the top of the well bore.

6. In combination: a string of pipe adapted to be lowered within a well bore; a coupling device movable longitudinally through said pipe and including an initially retracted coupling member; a well tool secured to said coupling device and depending therefrom and movable longitudinally through said pipe; said pipe having stop means therein at its lower portion; said coupling device having stop means above said coupling member engageable with said other stop means to locate said well tool substantially below the lower end of said pipe and to prevent further downward movement of said coupling member relative to said pipe; fluid actuated means including a tubular mandrel engageable with said coupling member for expanding said coupling member outwardly into coupling engagement with said pipe after engagement or" said stop means with each other; said fluid actuated means being responsive to the pressure of the fluid in said pipe to eX- pand said couplin member; said tubular mandrel communicating with said well tool and with the pipe above said mandrel to conduct fluid from said pipe through said mandrel to the interior or" said well tool; seal means between said coupling device and pipe preventing fluid flow erebetween when said stop means are engaged with each other to cause all or" the fluid pumped down the pipe to flow through the tubular mandrel into said well tool; means for transmitting downwardly directed thrust from said pipe to said coupling device and to said tool; means for retracting said coupling member from coupling engagement with said pipe to enable said coupling device and tool to be withdrawn through said pipe to the top of the well bore; and cutter means on said coupling member having an eilective cutting diameter greater than the outside diameter of said pipe when said coupling member is in expanded position.

7. In combination: a string of pipe adapted to be lowered within a well bore; a coupling device movable longitudinally through said pipe and including an initially retracted coupling member; an apparatus including a drill bit secured to said coupling device and depending therefrom and movable through said pipe; a whipstock releasably attached to said apparatus and movable through said pipe; said pipe having stop means therein at its lower portion; said coupling device having stop means above said coupling member engageable with said other stop means to locate said drill bit and whipstock substantially below the lower end of said pipe and to prevent further downward movement or" said coupling member relative to said pi e; fiuid actuated means including a tubular mandrel engageable with said coupling member for expanding said coupling member outwardly into coupl ng engagement with said pipe after engagement of said stop means with each other; said fluid actuated means being responsive to the pressure of the fluid in said pipe to expand said coupling member; said tubular mandrel communicating with said apparatus and with the pipe above said mandrel to conduct fluid from said pipe through said mandrel to the interior of said apparatus; seal means between said coupling device and pipe preventing fluid flow therebetween when said stop means are engaged with each other to cause all of the fluid pumped down the pipe to flow through the tubular mandrel into said apparatus; means for transmitting downwardly directed thrust from said pipe to said coupling device and to said drill bit and whipstock; means for retracting said coupling member from couphng engagement with said pipe to enable said coupling device and drill bit to be withdrawn through said pipe to the top of the well bore; and cutter means on said coupling member having an ellective cutting diameter greater than the outside diameter of said pipe when said coupling member is in expanded position.

8. In combination: a string of pipe adapted to be lowered within a well bore; a coupling device movable longitudinally through said pipe and including an initially retracted coupling member; a core bit apparatus secured to said coupling device and depending therefrom and movable longitudinally tlnough said pipe; said pipe having stop means therein at its lower portion; said coupling device having stop means above said coupling member engageable with said other stop means to locate said core bit apparatus substantially below the lower end of said pipe and to prevent further downward movement of said coupling member relative to said pipe; fluid actuated means including a tubular mandrel engageable with said coupling member for expanding said coupling member outwardly into coupling engagement with said pipe after engagement of said stop means with each other; said fluid actuated means being responsive to the pressure of the fluid in said pipe to expand said coupling member; said tubular mandrel communicating with said core bit appae ratus and with the pipe above said mandrel to conduct fluid from said pipe through said mandrel to the interior of said core bit apparatus; seal means between said cou pling device and pipe preventing fluid flow therebetween when said stop means are engaged with each other to cause all of the fluid pumped down the pipe to flow through the tubular mandrel into said core bit apparatus; means for transmitting downwardly directed thrust from said pipe to said coupling device and to said core bit apparatus; means for retracting said coupling member from said coupling engagement with said pipe to enable said coupling device and core bit apparatus to be withdrawn through said pipe to the top of the well bore; and cutter means on said coupling member having an effective cutting diameter greater than the outside diameter of said pipe when said coupling member is in expanded position.

9. In combination: a string of pipe adapted to be lowered within a well bore; a coupling device movable longitudinally through said pipe and including an initially retracted coupling member; a fiuid turbine secured to said coupling device and depending therefrom and movable longitudinally through said pipe; a drill bit secured to said turbine and having initially retracted cutters thereon ex pandible laterally outwardly, said cutters when in retracted position enabling said drill bit to be moved longitudinally through said string of pipe; means for expanding said cutters laterally outwardly to drill a hole diameter greater than the outside diameter of said pipe; said pipe having stop means thereon at its lower portion; said coupling device having stop means above said coupling member engageable with said other stop means to locate said fluid turbine and drill bit substantially below the lower end of said pipe and to prevent further downward movement of said coupling member relative to said pipe;

fluid actuated means including a tubular mandrel engageable with said coupling member for expanding said coupling member outwardly into coupling engagement with said pipe after engagement of said stop means with each other; said fluid actuated means being responsive to the pressure of the fluid in said pipe to expand said coupling member; said tubular mandrel communicating with said fiuid turbine and with the pipe above said mandrel to conduct fluid from said pipe through said mandrel to the interior of said fluid turbine to rotate the same and the drill bit secured thereto; seal means between said coupling device and pipe preventing fluid flow therebetween when said stop means are engaged with each other to cause all of the fluid pumped down the pipe to how through the tubular mandrel into said fluid turbine; means for transmitting downwardly directed thrust from said pipe to said coupling device and to said turbine and drill bit; and means for retracting said coupling member from coupling engagement with said pipe to enable said coupling device and said turbine and drill bit to be withdrawn through said pipe to the top of the well bore.

References Cited in the file of this patent UNITED STATES PATENTS 

1. IN COMBINATION: A STRING OF PIPE ADAPTED TO BE LOWERED WITHIN A WELL BORE; A COUPLING DEVICE MOVABLE LONGITUDINALLY THROUGH SAID PIPE AND INCLUDING AN INITIALLY RETRACTED COUPLING MEMBER; A WELL TOOL SECURED TO SAID COUPLING DEVICE AND DEPENDING THEREFROM AND MOVABLE LONGITUDINALLY THROUGH SAID PIPE; SAID PIPE HAVING STOP MEANS THEREIN AT ITS LOWER PORTION; SAID COUPLING DEVICE HAVING STOP MEANS ABOVE SAID COUPLING MEMBER ENGAGEABLE WITH SAID OTHER STOP MEANS TO LOCATE SAID WELL TOOL SUBSTANTIALLY BELOW THE LOWER END OF SAID PIPE AND TO PREVENT FURTHER DOWNWARD MOVEMENT OF SAID COUPLING MEMBER RELATIVE TO SAID PIPE; FLUID ACTUATED MEANS INCLUDING A TUBULAR MANDREL ENGAGEABLE WITH SAID COUPLING MEMBER FOR EXPANDING SAID COUPLING MEMBER OUTWARDLY INTO COUPLING ENGAGEMENT WITH SAID PIPE AFTER ENGAGEMENT OF SAID STOP MEANS WITH EACH OTHER; SAID FLUID ACTUATED MEANS BEING RESPONSIVE TO THE PRESSURE OF THE FLUID IN SAID PIPE TO EXPAND SAID COUPLING MEMBER; SAID TUBULAR MANDREL COMMUNICATING WITH SAID WELL TOOL AND WITH THE PIPE ABOVE SAID MANDREL TO THE INTERIOR OF SAID WELL PIPE THROUGH SAID MANDREL TO THE INTERIOR OF SAID WELL TOOL; SEAL MEANS BETWEEN SAID COUPLING DEVICE AND PIPE PREVENTING FLUID FLOW THEREBETWEEN WHEN SAID STOP MEANS ARE ENGAGED WITH EACH OTHER TO CAUSE ALL OF THE FLUID PUMPED DOWN THE PIPE TO FLOW THROUGH THE TUBULAR MANDREL INTO SAID WELL TOOL; MEANS FOR TRANSMITTING DOWNWARDLY DIRECTED THRUST FROM SAID PIPE TO SAID COUPLING DEVICE AND TO SAID TOOL; AND MEANS FOR RETRACTING SAID COUPLING MEMBER FROM COUPLING ENGAGEMENT WITH SAID PIPE TO ENABLE SAID COUPLING DEVICE AND TOOL TO BE WITHDRAWN THROUGH SAID PIPE TO THE TOP OF THE WELL BORE. 